MT830-MT831_TD_eng_V1.7

MT830-MT831_TD_eng_V1.7.docx

Energy Measurement and Management

MT830/MT831Three-phase electronic multi-function meter for industry

Technical DescriptionEAD 020 611 368

Version 1.7, 27.05.2013



Table of contents:1. List of standards ....................................................................................................32. Safety ......................................................................................................................4

2.1. Responsibilities .................................................................................................42.2. Safety instructions .............................................................................................4

3. Introduction ..........................................................................................................114. Meter characteristics ...........................................................................................125. Constituent parts .................................................................................................14

5.1. Measuring system ...........................................................................................145.2. Microcomputer.................................................................................................155.3. Real time clock ................................................................................................155.4. LEDs................................................................................................................15

6. Multi-tariff registration.........................................................................................167. Maximum demand indicator ...............................................................................168. Load Profile ..........................................................................................................169. Registration of energy / power ...........................................................................1610. Display ................................................................................................................17

10.1. Keys...............................................................................................................1811. Communication interfaces................................................................................18

11.1. IR communication interface...........................................................................1811.1.1. Meter reading in absence of measuring voltages (option) .....................18

11.2. RS-485 interface ...........................................................................................1911.3. RS-232 interface ...........................................................................................2011.4. CS-communication interface .........................................................................21

12. Input /output module (MT831 meter only) .......................................................2113. Communication module (MT831 meter only) ..................................................2314. Fraud protection ................................................................................................24

14.1. Detection of meter cover and terminal cover opening ..................................2415. Handling with the meter ....................................................................................2516. Connection procedure.......................................................................................25

16.1. 3phase 3wire connection...............................................................................2617. Housing...............................................................................................................26

17.1. Terminal block ...............................................................................................2817.2. Current terminals...........................................................................................2817.3. Auxiliary voltage terminals.............................................................................2917.4. Sliding voltage bridge (at direct connected meter)........................................2917.5. Cop5 terminal ................................................................................................3017.6. Dimensions....................................................................................................30

18. Sealing ................................................................................................................3119. Maintenance .......................................................................................................3120. Lifetime ...............................................................................................................3121. Technical data ....................................................................................................3222. Type designation ...............................................................................................35

22.1. Meter type designation..................................................................................3522.2. Input-output module type designation (for MT831 meter only) .....................36

22.2.1. Input/output module options: ..................................................................3622.3. Communication module type designation (for MT831 meters only) .............37

22.3.1. Communication module options: ............................................................3723. Configuring a PC modem..................................................................................4124. Appendix A: OBIS codes and data names ......................................................4725. Appendix B: Log book events ..........................................................................5626. Appendix C: Connection diagrams..................................................................58



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Iskraemeco, d.d. reserves the right to change these document at any time without prior notice. No part of this document maybe reproduced, stored or transmitted in any form whatsoever without prior written approval of Iskraemeco, d.d..This document is for information only. The content of this document should not be construed as a commitment,representation, warranty, or guarantee for any method, product, or device by Iskraemeco, d.d.

and are registered trademarks of Iskraemeco, d.d.. The contents of this documentare the copyrighted (registered and unregistered) or trademarked property of Iskraemeco, d.d. and are protected underapplicable trademark and copyright law. Unauthorized use may be subject to criminal and material liability.

1. List of standards

IEC 60068-2-1 Environmental testing – Part 2-1: Tests – Test A: Cold, IEC 60068-2-2 Environmental testing – Part 2-2: Tests – Test B: Dry heat, IEC 60068-2-30 Environmental testing – test Db: Damp heat cyclic test, Variant 1, IEC 61000-4-2 Electromagnetic compatibility (EMC) - Part 4-2: Testing and measurement, techniques - Electrostatic discharge immunity test, IEC 61000-4-3 Electromagnetic compatibility (EMC) - Part 4-3: Testing and measurement, techniques - Radiated, radio-frequency, electromagnetic field immunity test & IEC 61000-4-20 Testing

and measurement techniques - Emission and immunity testing in transverse electromagnetic (TEM)waveguides,

IEC 61000-4-4 Electromagnetic compatibility (EMC) - Part 4-4: Testing and measurement, techniques - Electrical fast transient/burst immunity test, IEC 61000-4-5 Electromagnetic compatibility (EMC) - Part 4-5: Testing and measurement, techniques - Surge immunity test, IEC 61000-4-6 Electromagnetic compatibility (EMC) - Part 4-6: Testing and measurement, techniques - Immunity to conducted disturbances, induced by radio-frequency fields, IEC 61000-4-12:1995 Electromagnetic compatibility (EMC) - Part 4-12: Testing and measurement

techniques - Oscillatory waves immunity test, CISPR 22 (1997) + A1 (2000), IEC 61000-4-20 (2003) Radio interference suppression, IEC 62052-11 Electricity metering equipment (AC) – General requirements, tests and test conditions –

Metering equipment, IEC 62053-21 Electricity metering equipment (a.c.) - static meters for active energy (classes 1 and 2), IEC 62053-22 Electricity metering equipment (a.c.) - static meters for active energy (classes 0.2 and

0.5), IEC 62053-23 Electricity metering equipment (a.c.) - static meters for reactive energy (classes 2 and 3), IEC 62056-21 Electricity metering - Data exchange for meter reading, tariff and load control – Direct

local data exchange, IEC 60695-2-11 Fire hazard testing part 2-11: Glowing/hot-wire based test methods - Glow-wire

flammability test method for end-products, EN / IEC 60068-2-75 Environmental testing - Part 2-75: Tests - Test Eh: Hammer tests, EN 50470-1 Electricity metering equipment (a.c.) - Part 1: General requirements, tests and test

conditions - Metering equipment (class indexes A, B and C), EN 50470-3 Electricity metering equipment Static meters for active energy, classes A, B and C, draft IEC 62053-24, Electricity metering equipment (AC.) - Particular requirements – Static meters for

reactive energy (classes 0,5 S, 1 S and 1), EN / IEC 60068-2-27 Basic envirionmental testing procedures - Tests - Tests Ea and guidance: Shock, EN / IEC 60068-2-6 Basic envirionmental testing procedures - Tests - Tests Fc: Vibration (sinusoidal).



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MT830/MT831 ─ Three-phase electronic multi-function meter

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2. Safety

2.1. ResponsibilitiesThe owner of the meter is responsible to assure that all authorized persons who work with the meter read andunderstand the parts of the User Manual and Installation and Maintenance Manual that explains the safehandling with the meter.

The personnel must be sufficiently qualified for the work that will be performed. The installation personnel mustpossess the required electrical knowledge and skills, and must be authorised by the utility to perform theinstallation procedure.

The personnel must strictly follow the safety regulations and operating instructions, written in the individualchapters in this User Manual and in the Installation and Maintenance Manual.

The owner of the meter respond specially for the protection of the persons, for prevention of material damageand for training of personnel.

2.2. Safety instructions

CAUTION: At the beginning of handling with the meter, the meter should be carefully taken out of thebox where it was packed. This should prevent the meter from falling as well as any other external or internaldamage to the device and personal injuries. Should such an incident occur despite all precautions, the metermay not be installed at the metering point as such damage may result in different hazards. In such case themeter needs to be sent back to the manufacturer for examination and testing.

CAUTION: The edges of the seal wires are sharp.

CAUTION: The temperature of the terminal block of the connected and operating meter may rise,therefore the temperature of the terminal cover may rise as well.

DANGER: In case of any damage inside the meter (fire, explosion...) do not open the meter.

CAUTION: The meter may be used only for the purpose of measurement for which it was produced.Any misuse of the meter will lead to potential hazards.

WARNING: Safety measures should be observed at all times. Do not break the seals or open themeter at any time!

The content of this Technical description provides all information necessary for safe selection of MT174 meter.

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See the complete Technical description for detailed technical features of MT174 and its intended use.

It must be consulted in all cases where symbol is marked in order to find out the nature of thepotential hazards and any actions which have to be taken to avoid them.

The meter installation procedure is described in this Technical description. For safety reasons the followinginstructions should be followed.

Only the properly connected meter can measure correctly. Every connecting error results in afinancial loss for the power company.

DANGER: The MT174 electricity meter is the device, connected to the power supply. Any unauthorizedmanipulation of the device is dangerous for life and prohibited according to the applicable legislation. Anyattempt to damage the seals as well as any unauthorized opening of the terminal or meter cover is strictlyforbidden.

DANGER: Breaking the seals and removing the terminal cover or meter cover will lead to potentialhazards because there are live electrical parts inside.

Installation companies shall implement a training policy that ensures that new installers areadequately trained, understand risk and safety issues and possess the relevant skills before they commenceoperational duties.

The installer will need to recognise and understand different metering installations, the meter typeand various equipments associated with those installations applicable to the successful installation of theelectricity meter.

The installer must consult and comply with local regulations and read the installation instructionswritten in this Technical description.

The installer will be considered as a public face by both the power company and its customers. Theinstaller shall adopt the highest standards of behaviour and be respectful to clients and members of the public.

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Before the installation procedure check if the metering point is correctly prepared for meterinstallation. The metering point must always be left clean and in order.

The work location shall be defined and clearly marked. Adequate working space as well as means ofaccess and lighting shall be provided at all parts of an electrical installation on, with, or near which any workactivity is to be carried out. Where necessary, safe access to the work location shall be clearly marked.

WARNING: The metering point must not be exposed to running water or fire.

WARNING: Meter installation may not be performed by unauthorised and untrained personnel. Suchpersons are not allowed to cut the seals and open the terminal or meter cover as contact with the live parts ofthe meter is dangerous for life.

DANGER: Opening the terminal or meter cover is dangerous for life because there are live partsinside.

CAUTION: The installer is expected to fully understand the risks and safety issues involved inelectrical installations. The installer shall be aware at all times of the potential hazard of electrical shock andshall exercise due to caution in completing the task!

Installation personnel must possess the required electrical knowledge and skills and must beauthorised by the utility to perform the installation procedure.

The installer is obligated to perform the installation procedure in accordance with the nationallegislation and internal norms of the utility.

National legislation can set out the minimum age and the criteria for competence of installers. Wherethere are no national requirements for competence, the following criteria shall be used in assessing thecompetence of installers: knowledge of electricity, experience of electrical work, understanding of the installationto be worked on and practical experience of that work, understanding the hazards which can arise during thework and the precautions to be observed, ability to recognize at all times whether it is safe to continue working.

According to the basic principles, either the nominated person in control of the electrical installationor the nominated person in control of the work activity shall ensure that specific and detailed instructions are

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given to the personnel carrying out the work before starting and on completion of the work. Before starting work,the nominated person in control of the work activity shall give notification to the nominated person in control ofthe electrical installation, of the nature, place and consequences to the electrical installation of the intendedwork.

Tools, equipment and devices shall comply with the requirements of relevant National or InternationalStandards where these exist. Tools, equipment and devices shall be used in accordance with the instructionsand/or guidance provided by the manufacturer or supplier. Any tools, equipment and devices provided for thepurpose of safe operation of, or work on, with, or near electrical installations shall be suitable for that use, bemaintained and be properly used.

Personnel shall wear clothing suitable for the locations and conditions where they are working. Thiscould include the use of close-fitting clothing or additional PPE (personal protective equipment).

CAUTION: The installer must be correctly equipped with personal protection equipment (PPE) anduse the appropriate tools at all times during the installation.

CAUTION: Working procedures are divided into three different procedures: dead working, liveworking, and working in the vicinity of live parts. All these procedures are based on the use of protectivemeasures against electric shock and/or the effects of short-circuits and arcing.

The installer must be informed if the national legislation permits the work on the installation undervoltage – live work, and must follow the rules of legislation.

Depending on the kind of work, the personnel working in such conditions shall be instructed or skilled.Live working requires the use of specific procedures. Instructions shall be given how to maintain tools,equipment and devices in good working order and how to verify them before working.This subclause deals with the essential requirements (“the five safety or golden rules”) for ensuring that theelectrical installation at the work location is dead and secure for the duration of the work.This shall require clear identification of the work location. After the respective electrical installations have beenidentified, the following five essential requirements shall be undertaken in the specified order unless there areessential reasons for doing otherwise: disconnect completely (1.), secure against re-connection (2.), verify thatthe installation is dead (3.), carry out earthing and short-circuiting (4.) and provide protection against adjacentlive parts (5.).

CAUTION: Do not attempt to install the meter before you have isolated the installation site from thenetwork!

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DANGER: The relevant preliminary fuses must be removed before making any modifications to theinstallation, and kept safe until completing the work to prevent the unnoticed reinsertion.

DANGER: The current transformer secondary circuits must not be opened when current is flowing inthe primary circuit. This would produce a dangerous voltage of several thousands volts at the terminals and theinsulation of the transformer would be destroyed.

DANGER: Connecting the meter into the network under voltage is dangerous for life so the conductorsat the metering point must not be connected to any voltage source during the connection procedure. The meterconnection procedure may only be performed by well-trained and adequately authorized personnel.

CAUTION: Only one wire or ferrule may be connected in one terminal. Otherwise, the terminal couldbe damaged or the contact could not be made properly.

CAUTION: Do not use cables other than those prescribed for the installation site.

DANGER: The insulation of the connecting cable must extend over the whole visible part of the cable.There must be no further bare part of the cable visible above the terminal edge. Touching live parts isdangerous for life. The stripped part of the connecting wire should be shortened if necessary.

CAUTION: At the end of installation at the metering point no cable should stay unconnected orhanging freely from the metering point.

The meter has to be mounted on a smooth vertical surface and fixed at 2 or 3 points with screwsusing the proper torque. (the meter has two attachment holes and, optionally, a top hanger).

The meter is intended to be mounted at an indoor metering point, in a meter cabinet, secured againstthe undesired access of unauthorized persons. Only scroll push button may be accessible from the outside. Donot expose meter surface to very high temperatures even though the surface is made of inflammable plastics toprevent fire.

CAUTION: Electrical connection: mounting cables must be properly dimensioned and of propershape. They must be mounted using the proper torque. The meter should be connected according to the meterconnection diagram that is attached to the inner side of the meter terminal cover. Screws on the current terminal

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must be tightened to proper torque. The protective earth connector shall be connected first and it shall not beremoved until the meter is fully isolated from the network.

CAUTION: If it is possible to install the meter without isolation from the network, i.e. on live network,then appropriate instructions and safety warnings shall be provided.

CAUTION:Specific aspects and safety hazards related to external voltage and current transformers,auxiliary supplies and local generation shall be covered.

DANGER: The current transformer circuits must be closed before commissioning and functional checkof the meter.

DANGER: The preliminary fuses must be re-inserted before commissioning and functional check of themeter.

CAUTION Seals on the meter have to be checked at the end of the installation procedure so that thefinal customer can not come into contact with live parts of the meter.

DANGER: If the terminal cover is not screwed tight, there is a danger of contact with the connectionterminals. Contact with live parts of the meter is dangerous for life.

CAUTION: For safety reasons, replace the terminal cover immediately after the installation procedureand fix it with fixing screws.

DANGER: When switching on the power beware of the risk of electric shock at all times!

The functional check requires voltage to be applied and load applied to all phases. If export ispossible, determine first the energy direction present. If no mains voltage is present, commissioning andfunctional check must be performed at a later date.

No maintenance is required during the meter’s life-time. The implemented metering technique, built-incomponents and manufacturing process ensure high long-term stability of meters, so that there is no need fortheir recalibration during their life-time.

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If a battery is built into the meter, its capacity is sufficient to backup all meter functions like RTC andtampering functions for its entire life-time.

In case the service of the meter is needed, the requirements from the meter installation proceduremust be observed and followed.

Cleaning of the meter is allowed only with a soft dry cloth. Cleaning is allowed only in upper part of the meter –in region of the LCD. Cleaning is forbidden in the region of terminal cover. Cleaning can be performed only bythe personnel, responsible for meter maintenance.

CAUTION: Do not try to erase the markings, laser printed on the name plate.

DANGER: Never clean soiled meters under running water or with high pressure devices. Penetratingwater can cause short circuits. A damp cleaning cloth is sufficient to remove normal dirt such as dust. If themeter is more heavily soiled, it should be dismounted and sent to the responsible service or repair centre.While dismounting the meter observe and follow the same safety regulations and instructions as for installationof the meter.

CAUTION: Visible signs of fraud attempt (mechanical damages, presence of a liquid, etc.) must beregularly checked. The quality of seals and the state of the terminals and connectiog cables must be regularlychecked. If there exist a suspicioun of incorrect operation of the meter, the local utility must be informedimmediatelly.

After the end of the meter’s lifetime, the meter should be treated according to the Waste Electric andElectronic Directive (WEEE).

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3. Introduction

MT830/MT831 three-phase electronic multi-function meter is intended for measuring active and apparentenergy in two flow directions, reactive energy in four quadrants as well as imported and exported, maximalpower of the above stated energies, registration of load curves and quality parameters of supplied electricenergy in three-phase three- and four-wire networks. The meters can be connected directly, semi-indirectlyor indirectly. They comply with the IEC 62052–11, IEC 62053-21, EN 50470-3, IEC 62053-22 and IEC62053-23 standards, VDEW demands, and they are manufactured in compliance with the ISO 9001standard. MT83y meters comply with the IEC 50579 standard and the current valid FNN instructions"Leitfaden zur Bewertung der Zuverlässigkeit und Messbeständigkeit von Elektrizitätszählern undZusatzeinrichtungen" from november 2011. MT83y meters can be installed in photovoltaic and cogenerationsystems.

The meter consists of a polycarbonate housing, electronics for measuring and processing measuring data,input/output as well as communication electronics.

Two different meter versions are available: MT830 - a “closed” meter version with additional six terminals, which could be used for:

o communication interface,o functional or impulse inputs,o functional outputs,o external power supply.

Figure 1: MT830 – a “closed” meter version

MT831 – a modular meter version with communication (MK) and input/output (MIO) module which couldbe subsequently built into the meter and six additional terminals.

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Figure 2: MT831 – a modular meter version

4. Meter characteristics

Measuring active energy/power. Measuring reactive energy/power in four quadrants and/or a sum of energies by individual quadrants

(e.g. Q1+Q2 and Q3+Q4). Measuring apparent energy/power. Calculating cumulative power. Measuring and displaying parameters of energy quality:

rms voltage values by phases, current by phases, harmonic components in voltage and current (up to the 8th harmonic), power factor per phase and total, phase angle between phase voltage and current, voltage failures.

Multi-tariff registration. Load profiles (P.01, P.02). Log-books (P.98, P.99). Different display modes on LCD. Meter reading in case of power down (“no power reading” option with SONDA 6 (option)). VDEW designed LCD presence of phase voltages, energy flow direction, units and 11 statuses. Communications. IR interface for a local readout and meter programming (IEC 62056-21). Auxiliary terminals: the main meter board (MT830 & MT831) could be equipped with up to six auxiliary

terminals, which could be: Communication on board port (MT830 only)

MT830 meter could be equipped with CS interface or RS-485 interface or RS-232 interface.

Communication with the meter is performed in compliance with the IEC 62056-21 standard, mode C. Themeter operation is not affected during communication.

Type of communication: Serial asynchronous half-duplex ISO 1177

1 start bit

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7 data bits 1 bit parity – even 1 stop bit

data transfer rate: 300, 600, 1200, 2400, 4800, 9600, 19200 Baud Each communication port supports “fix” baud rate (for use of transparent telephone modems) or

communication protocol according to IEC 62056-21 standard (communication sequence is started with 300baud). Communication parameters in the meter are programmable. The meter enables separate read out(different data) via IR and other communication interface at the same time.

The MT831 meter could be equipped with different communication modules (MK). Two inputs (3 terminals) are used:

functional or impulse inputs.

Control voltage is from 100 V….240 V AC/DC. At MT831 meter additional inputs & outputs could be implemented in input/output module (I/O module).

Electrical characteristics: OFF state <= 30 V, ON state >= 45 V, internal resistance 190kOhm, switch on delay typical 10ms at 240V.

Four outputs in two functional groups (6 terminals). External power supply (2 terminals).

Terminal Terminaldesignation

Additionalexplanation

30 50 – 240 VAC/DC External power supply

31 50 – 240 VAC/DC External power supply

Table 1: Terminals for external power supply

Modular construction at the MT831 meter: MT831 could be upgraded with input/output (MIO) andcommunication (MK) module.

Fraud detection: detection of a meter cover and a terminal cover opening.

Quality: High accuracy as well as time stability of measurement. High reliability of operation and long life span (20 years).

High immunity to EMC disturbances. Simple and fast assembly. A compact plastic housing is made of high quality self-extinguishable materials and is resistant to water

and dust penetration (IP53). Environment friendly: a meter is made of the materials that can be recycled or are not dangerous for the

environment.

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5. Constituent partsThe meter consists of the following units:

measuring systems, microcontroller with external memory, real time clock, LCD, optical interface, keys, LEDs , power supply :

o internal three phase switcher,o external power supply,o power supply via optical probe (“no power” reading option with SONDA 6).

LCD

CPU

OUTPUTS

INPUTS

AUX Power supplyfrom optical probe

BUTTONSTAMPER

MEMORY: -FLASH -SRAM -FRAM

RTC

BACKU

O

CS--------------- RS-232--------------- RS-485

Switching powersupplymultirange

Externalswitching power

MEASSYS. 1 R

MEASSYS. 2 S

MEASSYS. 3 T

Adapter forI/O and COMM Modul

I/OModul

COMM Modul

Figure 3: A meter block diagram

5.1. Measuring systemThe measuring systems are based on Rogowski coils that measure changes on the induced voltage. Currentflows through a current coil. Voltage is induced inside the air coils due to alternate magnetic field. There are twoRogowski coils on each phase.

The measuring system is made of:1. current coil frame2. current coil3. two Rogowski coils4. PCB

Figure 4: Measuring system

A measuring system measures induced voltage on measuring coils which is proportional to the current on input.The first coil measures “load” energy and the second one is a compensation coil which measures outsidedisturbances. Compensation value is subtracted from a measuring element.

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An output signal from Rogowski coils is related to the input of the measuring integrated current. A signal isintegrated, amplified and multiplied with measuring voltage and sent to the microprocessor.

Figure 5: Measuring principle

Sensors and circuits are protected from overvoltage. Influences of disturbance quantities are negligible, whichassures high meter reliability.

5.2. MicrocomputerA microcomputer enables:

meter functions by customer's specification, storing measuring data and parameters, storing measuring data for previous billing periods (factory settings is 15 billing periods), demand calculations, Load Profile function, compensating measuring protocol of voltage and current transformers, Logbook, Display control, certain supervision and control meter functions for measuring phase voltages, measuring phase voltages, measuring harmonic components in current and voltage, measuring frequency.

Operation of the microcomputer is controlled by a special Watch-dog supervisor circuit.

5.3. Real time clockA real time clock is controlled by a 32kHz quartz oscillator. The clock accuracy complies with the IEC 61038standard requirements. Back up power supply source is built in the meter. It is usually a supercapacitor or?? anLi battery which is directly soldered to the main printed circuit board. The supercapacitor assures energy for 250hours of the clock operation in case of a complete power supply failure, while an Li battery assures 10 years ofoperation, with time life span of 20 years.A real time clock generates:

a measuring period for power and a registration period for load profile, tariff programs, season changeover, transition to day light saving period and vice-versa, time stamps of individual events (a time-stamp consists of a date, an hour, a minute and a second of

the event).

5.4. LEDsTwo LEDs are built in the meter:

left - active (imp/kWh), right - reactive (imp/kvarh) or apparent (imp/kVAh) (programmable).

They enable meter calibration. Impulse constants depend on nominal current and voltage and areprogrammable values.

Factory settings: Direct connected meter

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o 3x230/400 V, 5(60) A 1.000 imp/kWho 3x230/400 V, 5(120) A 500 imp/kWh

Transformer operated metero 3x57.7/100 …. 3x240/415V, 5(6)A 10.000 imp/kWh

To reduce the control time a special factory test mode is built in the meter, which increases LED constants10 times higher, in comparison with a normal operating mode. After power down/up event, all constants takethe original factory settings.

6. Multi-tariff registrationThe meter enables registration of energy and power by separate tariff schemes. Up to 8 tariffs for energy anddemand could be registered (factory settings - 4 tariffs). The meter is equipped with 160 tariff registers. Time ofswitching individual tariff is defined by hour and minute with a resolution of 1 minute. A number of periods in aday where one or several tariffs can be valid is defined with configuration. The same is valid for different dailytariff programs. Up to 32 various types of a day (a day in a week and a holiday) can be defined. A number ofseasons in a year (factory settings - 4 seasons) is defined with configuration. Besides a current tariff program,the so-called sleeping tariff programs can be defined. They are activated at previously defined dates. Anoptional number of holidays can be defined. A century-old calendar is built in the meter.

7. Maximum demand indicatorMaximum demand can be measured with a fixed or a sliding measuring period. A measuring period can be setfrom 1 minute to 60 minutes with a 1-minute resolution. It is possible to measure maximum demands for:

active energy in both flow directions, reactive energy in four quadrants as well as a sum of energies by individual quadrants (e.g. Q1+Q2 and

Q3+Q4), apparent energy in both energy-flow directions.

Maximum demands are registered by individual tariffs and cumulatively.Configuration of blocking the measurement of maximum demand for a certain time that follows a period ofnetwork voltage failure is also available.

8. Load ProfileA programmable data recorder enabling registration of a load profile is built in the meter:

active, apparent power and energy (cumulative or absolute values) three-phase values in bothenergy flow directions,

reactive power or energy (cumulative or absolute values) in four or combined quadrants (e.g. Q1+Q2and Q3+Q4),

rms values of phase voltages, distortion factor, individual meter statuses (power supply failure, alarms).

A registration period or a load profile can be set within the range from 1 to 60 minutes. Two load profiles (P.01and P.02) could be implemented in the meter. The first one (P.01) is normaly used for registering energy ordemand, and the second one for registering the last average of voltage, current and power factor. Last averageregistration is related to the measuring period. Load profile periods and measurement period are independendfrom each other.

9. Registration of energy / powerThe MT830/MT831 meter has three measuring systems and could be used in a three-phase three-wire or three-phase four-wire networks.

Registration types: Note: registration type is defined at meter ordering. Vector registration ( Li),

when the vector sum of energies is positive, the meter registers A+ energy; when the vector sum of energies is negative, the meter registers A- energy

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Example: (phase load is the same)Phase: L1 L2 L3Load: +A -A +A

Total registration (1.8.0) (+A) + (-A) + (+A) = +ATotal registration (2.8.0) 0Meter registers +A (one phase load!!).

Arithmetical registration the meter could register A+ and A- energy in the same time


Total registration:Positive direction (1.8.0) (+A) + (+A) = 2*(+A)Negative direction (2.8.0) -A

If the second phase is wrongly connected, the meter also registers this energy with such registration type.

Absolute active energy A


Total registrationPositive direction (1.8.0) +A+-A++A=3*(+A)

With such registration the meter registers only “imported” energy, also in case of “wrong” connection.

For measuring reactive energy a natural connection is used. Internal register provides for a correspondingvoltage and current phase shift.

MT830/MT831 meters could be provided with: three measuring systems (MT830 – T1 /MT831 – T1) – transformer connected.

10. DisplayLCD is designed according to the VDEW requirements.

Figure 6: LCD

The measuring data on LCD are displayed with eight 7-segment 8mm x 4mm high numbers. Displayed data areidentified with five-digit OBIS identification codes (IEC 62056 – 61), 6mm x 3mm high numbers. Dimension ofLCD (visible area) is 69mm x 20mm.

Meters have back-light illumination for easy data reading at metering place with bad light condition. The LCD isilluminated when any pushbutton is pressed. The illumination is switched-off after 3 minutes if no pushbuttonwas pressed at that time.A meter operates in different display modes

Automatic data circulation Auto ScrollTime between two register presentations in LCD is programmable.

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Because only 5 digits are used for identification, 9 previous register values are presented on theLCD.

Additional modes are accessible with a black and a red push-button.Displaying modes accessible with the black push-button: Manual data display – registers Std dAtA. Manual data display – network parameters (voltage, current, phase angle, etc.) Grid. Manual data display– Load Profile (P.01 and/or P.02 (programmable)). Presentation of the GSM modem parameters DiAg

C.C.3 signal level (should be higher than 17), C.C.4 GSM provider (1 – home provider, 5 – roaming), C.C.5 error code (should be 0).

Displaying modes accessible with the red push-button: Manual setting of time, date, etc. SET mode. Registers presented in Auto scroll mode with enhanced energy registers presentation TEST mode. Resetting the LCD statuses of meter and terminal cover opening Intrusion restart mode.

Format and data units are programmed. At transformer operated meters, displayed measuring data can beprimary or secondary.Besides measuring data, the energy flow direction, presence of phase voltages, display of individual events,meter statuses and alarms can be displayed.

10.1. KeysThe meter is equipped with three keys.Black DISPLAY key is used for transition from a basic to an extended data display mode.

Red RESET key is used for billing meter reset or, in combination with the DISPLAY key, for setting certainmeter parameters (SET, TEST or Intrusion restart meter operation mode). The RESET key is sealed separatelyor it can be locked.

PARAM key is under the meter cover and is used for setting meter parameters in the laboratory.

11. Communication interfacesAn optical communication interface is located on the meter basic board. One of communication interfaces thatare intended for remote meter readout (CS or RS-232 or RS-485) can be mounted on customer demand. Themeter is provided with two independent communication channels.

11.1. IR communication interfaceThe optical communication interface enables a user to set the meter parameters and read the measuring results(registers reading, logbook reading, load profile reading, reading individual registers, sending individualcommands).

11.1.1. Meter reading in absence of measuring voltages (option)On customer’s request, the meter can be equipped with additional electronics, which enables communicationvia an optical interface also in case of measuring voltages failure. This is enabled with a special probe (Sonda6). It is also possible to read meter data manually by means of the DISPLAY key.

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Figure 7: “No power” meter reading option with Sonda 6 (option for MT830/MT831)

11.2. RS-485 interfaceThe RS-485 serial interface enables communication with maximum transmission rate 19200 bauds. The MT830meters with a built-in RS485 interface are equipped with three auxiliary terminals. Up to 31 meters can beconnected to the RS485 interface with maximum distance of 1200m. In such configuration, the meter readout isobligatory with device address. For longer distances (more than few hundred meters), the use of terminationresistor of 120Ohm on each edge is recommended.

At MT830 meters three auxiliary terminals (Table 2) for MR485 communication interface are available:



27 A A terminal28 GND Common terminal29 B B terminal

Table 2: RS485 terminals designation for three auxiliary terminals

At MT831 meters the following communication modules with three auxiliary terminals (Table 2) for RS485communication interface are available:

MK-3-3: double RS485 communication, MKMB-3-e-3: MODBUS communication.

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At MT831 meters the communication modules with only two auxiliary terminals (Table 3) for RS485communication interface are also available:

MK – 38a-3: GSM/GPRS communication (+2x RS485), MK – f38-3: GSM communication(+2x RS485+CS), MK – 3-e-3: Ethernet (+2x RS485), MK – f39-3: ISDN(+2x RS485+CS), MK – 2-3: RS232 in RS485, MK – 1-3: CS in RS485.



27 A A terminal29 B B terminal

Table 3: RS485 terminals designation (withoud GND) for two auxiliary terminals

Figure 8: Meters connected to the modem via RS485 interface

11.3. RS-232 interfaceThe RS 232 serial interface enables communication with maximum transmission rate 19200 bauds. The MT830meters with built-in RS 232 interface are equipped with three auxiliary terminals or RJ11 connector.



27 RxD Rx terminal28 GND Common terminal29 TxD Tx terminal

Table 4: RS-232 terminals designation

Figure 9: RS-232 RJ11 terminal designation

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11.4. CS-communication interfaceThe CS interface (20mA current loop) complies with the DIN 66348 standard and is two-wire communication. Itenables communication with maximum transmission rate 9600 bauds. The MT830 meters with built-in CSinterface are equipped with two auxiliary terminals. Up to four meters can be connected to the CS interface withmaximum distance of 1500m. In such configuration, the meter readout is obligatory with a device address.



23 CS+ CS+ terminal24 CS- CS- terminal

Table 5: CS interface terminals designation

Figure 10: Meters connected to the modem via CS interface

.12. Input /output module (MT831 meter only)I/O modules are plug & play. Two versions regarding the internal programming are available:

Input – output module function is predefined in module EEPROMThe module is pre-programmed in the factory. After inserting the module into the meter, the meterautomatically accepts the module parameters (plug and play module). Terminals are marked according tothe VDEW requirements. The module can be re-programmed only in the factory.

Input – output module function is not predefined in module EEPROMThe function of input-output module terminals is defined when setting meter parameters which arespecified in the group “Input/output pins” MeterView 4 program.Terminal designations:

Cx for common terminals Tx for output terminals TEx for input terminals

where x is from 1 to n (a terminal number).

Standard versions are:- MIO-V12L51 4 outputs + 1 output + 1 input- MIO-V42L81 4 outputs + 4 outputs + 4 inputs- MIO-V12L41B11 4 outputs + 1 output 5A bistable rele + 1 input

Error on an input/output module does not influence in the meter operation.

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Figure 11: Input/output module (MT831 only)

Definition of input terminals:

Terminal Terminaldesignation Additional explanation

15 COM Common terminal for functional inputs

13, 33 TE1/2,TE3/4 Energy tariff input T1 – T4

14, 34 ME1/2,ME3/4 Demand tariff input M1 – M4

16 MPE External time/measurement periodsynchronization input

17 MZE External input for disabling of demandmeasurement

18 MREa Input a for external billing reset19 MREb Input b for external billing reset21 MKE1 Alarm input 122 MKE2 Alarm input 290 COM Common terminal for impulse inputs91 IME1 Impulse input 192 IME2 Impulse input 2

Table 6: Input terminals designation

Impulse inputs are realized as passive inputs. An impulse constant is programmable and could be different foreach impulse input. Maximum impulse frequency is 25 imp/sec.

Definition of output terminals:

Terminal Terminaldesignation Additional explanation

35 COM Common terminal36 MKA Alarm output37 MPA Measurement period output38 ERA+A Energy flow direction +A39 ERA+R Energy flow direction +R40 COM Common terminal41 +AA Pulse output for +A

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42 -AA Pulse output for -A43 +RA Pulse output for +R44 -RA Pulse output for -R45 RA1 Pulse output for RA146 RA2 Pulse output for RA247 RA3 Pulse output for RA348 RA4 Pulse output for RA452 COM Common terminal for 41 and 42 terminals54 COM Common terminal for 43 and 44 terminals56 COM Common terminal for 45 and 46 terminals58 COM Common terminal for 47 and 48 terminals59 COM Common terminal for terminals from 45 up to 4865 COM Common terminal

61, 63 TA1/2,TA3/4 Demand tariff outputs T1 – T4

62, 64 MA1/2,MA3/4 Demand tariff outputs M1 – M4

68 MRAa Output for external billing reset a69 MRAb Output for external billing reset b75 COM Common terminal71 LA1 Load control output 172 LA2 Load control output 2

Table 7: Output terminals designation

13. Communication module (MT831 meter only)Communication modules are plug & play. Two versions regarding the internal programming are available: Communication module parameters setting is predefined in the module EEPROM

The module is pre-programmed in the factory (baud rate, parity, stop bit, some special modem settings).After inserting the module in the meter, the meter automatically accepts the module parameters (a plugand play module).

Communication module parameters setting is not predefined in the module EEPROMAll settings regarding the communication modem accept from the meter parameters. The modem isautomatically initialized after predefined period or meters internal initializations.

Figure 12: Communication module parameters

Each module has two independent communication interfaces, which enables simultaneous meter reading.Communication interfaces are isolated from each other.Additional special programming (for example: PSTN modem is possible with the MeterView 4 program.

Communication module designation:MK – the 1st communication interface – the 2nd communication interface

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For example:MK – f38 – 3First communication interface (MK – f38 – 3):

f active CS interface, 3 RS-485 interface , 8 GSM modem,

(it is possible to establish multi drop communication via RS-485 and CS communication interface).

Second communication interface (MK – f38 – 3): 3 RS-485 - second (independent) RS-485 communication interface.

Besides communication towards the centre, the modules also offer possibility of cascade connection (a CSinterface and an RS485 interface). The module enables hot swap installation (modules can be changed or builtinto the meter during the meter operation). The modules are located under the terminal cover and are notsealed with a metrological seal. On costumer’s request, modules could be sealed with an unremovable sticker.The same communication module can be built into different meter types: MT831 and MT860. All modules are»plug & play« type. When the module is built in, it sends its identification code via a data bus. The module isautomatically recognized by the meter and is correspondingly controlled.The error on the communication module does not influence in the meter operation.

Figure 13: Communication module (MT831 only)

14. Fraud protectionThe meter is protected against fraud in several ways.

The meter cover and the terminal cover are sealed separately. The RESET key is sealed or locked with a lock. Commands and accesses to individual registers are protected with three password levels. All interventions into the meter are recorded in a logbook. Measuring data are stored in a nonvolatile memory on two places (a primary and a secondary copy).

14.1. Detection of meter cover and terminal cover openingMT830/MT831 meter detects the meter cover (MCO) and terminal cover (TCO) opening. Time and date of suchoccurrence are written in the meter Logbook. The state of the MCO and TCO opening could also be presentedin the status flags on the LCD.

When the meter is powered via measuring voltages or auxiliary power supply, the opening time stamp presentthe real (actual) time.

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Example:A terminal and a meter cover were opened during “normal” meter operation meter was powered bymeasuring voltages.

(060317115820)(0080) power down(060317125820)(0040) power up(060317132820)(0020) time setting(060317134520)(0020) time setting(060317135940)(811B) terminal cover opened(060317140015)(811D) meter cover opened

The meter also detects the TCO and MCO in case of power down but without the real time of such event.Meter electronics detects only opening event, while date and time in such case are related to the first power up.

Example:A terminal and a meter cover were opened during power down.

(060317115820)(0080) power down meter and terminal cover were opened during this time(060317145820)(0040) power up(060317145821)(811B) terminal cover opened(060317145821)(811D) meter cover opened

After installing the meter, at least TCO event is registered in the meter Logbook or in the status flag on the LCD.To restart the TCO and MCO registering “Intrusion Restart” function must be implemented. This function isaccessible by using the black and the red key or remotely by sending a special command into the meter.Intrusion Restart function is automatically done after power up event, parameter changing (when meter goesthrough the “Standby”).

After “Intrusion Restart”, the meter detects only one TCO and MCO opening.

Note: to detect the opening of the meter and the terminal cover, “Intrusion Restart” must beimplemented!

15. Handling with the meterTwo sets of tools are available:

For service programming and readout: MeterView 4 (Iskraemeco software), an optical probe, a PC, a table or a portable one (PC - desk-top, PC – laptop).The tool is intended for the operators who service or reprogramme the meters in the laboratory or in the

field.

For billing readout and programming: MeterRead (Iskraemeco software), for all types of palmtop PCs operating in the WinCE environment, an optical probe.

The tool is intended for readers in the field.

16. Connection procedure1. Meter assembly.2. Meter connection to network.3. Checking connection indication – a LED is lit.4. Checking correct connection – see LCD indications:

presence of all three phases - L1 L2 L3 all symbols are displayed, at least 1 phase is absent - L1 L3 absent phase is marked, wrong phase sequence - L1 L2 L3 symbols of wrongly connected phases are blinking.

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16.1. 3phase 3wire connection

For 3phase3wire connection with connected external power supply (E1) we recommend to use externalresistors.Iskraemeco d.d. can supply resistors kit if it is necessary.

Reason: with 3P3W connection and connected external power supply to the meter the neutral line (terminal 11on terminal block) is unstable. With using external resistors neutral is stable.

For more detailed information please contact Iskraemeco d.d. : [email protected].

Figure 14: Connection of the resistors

17. HousingThe meter housing is made of self-extinguishable polycarbonate that can be recycled. The housing assuresdouble insulation and IP53 protection degree against dust and water penetration. Meter dimensions and fixingdimensions comply with the DIN 43857 standard. A hook fixing is adapted by height. In case of a simpleversion, the mask does not have any bed for modules and the meter cover is extended.

Figure 15: A hook adjustable by height (MT830/MT831)

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Figure 16: Meter constituent parts

1 LCD2 Meter technical data3 IR optical interface4 Input/output module mark5 Legend of displaying registers on LCD6 Meter cover sealing screw7 Terminal cover8 Terminal cover sealing screw9 Communication module mark10 RESET key blocking element11 RESET key12 DISPLAY key13 Impulse diode – active and reactive energy14 Meter cover

1

2

3

4

5

6

7

8

14

13

1210119

28


Sliding voltage bridge

Figure 17: Terminal block constituent parts for direct connected meter Terminal block

17.1. Terminal blockA terminal block complies with the standard. It is made of high quality polycarbonate that assures: resistance tohigh temperatures, voltage breakdown and mechanical strength.

17.2. Current terminals

Direct connected meter:Connection terminals are made of nickel plated steel and have two screws per terminal.

Figure 18: Current terminals at direct connected meter version

Position 0

Position 1

Auxiliaryterminals

Terminalcoversealing

Additional voltageterminals

Terminal cover opening detector

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CT connected meter:Connection terminals are made of solid brass and have two screws per terminal.

Figure 19: Current and voltage terminals at CT connected meter version

17.3. Auxiliary voltage terminals

Direct connected meter:The meter can be equipped with max. four auxiliary voltage terminals (L1, L2, L3, N). They enable simpleconnection of additional external devices.

17.4. Sliding voltage bridge (at direct connected meter)Sliding voltage bridges are intended for fast and simple separation of a meter current and voltage circuit usedfor calibration or accuracy testing. In each phase of the connection terminal a special plastic slider is built in. Itcan be shifted up and down with a screwdriver. When a voltage bridge is in »0« position, it means that thevoltage part is separated from the current part, while in position »1« it is closed.

Figure 20: Sliding voltage bridge

Position 0: Voltage bridge is disconnected.Position 1: Voltage bridge is connected.

Different versions of sliding bridges exist at the direct connected MT83y meters: external connection,

Figure 21: External version of voltage bridges

internal connection (voltages bridges are accessible only by opening the meter cover).

Position 0

Positon 1

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17.5. Cop5 terminalAt Cop5 terminal block voltage terminals are covered:

Figure 22: Voltage terminals are covered with special Cop5 cover

17.6. Dimensions

Meter fixing dimensions comply with the DIN 43857 standard.

Figure 23: Meter fixing dimensions (MT830)

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Figure 24: Meter fixing dimensions (MT831)

18. SealingMeter cover and terminal cover can be sealed separatelly each with two sealing screws (Figure 16). The blockingelement of the Reset key can be sealed separatelly (Figure 16).

19. MaintenanceThe meter is designed and manufactured in such a way that it does not need maintenance during the entire meterlifetime. Measuring stability assures that no recalibration is required. The meter with the internal battery assuressufficient capacity for performing battery-supported functions for the entire lifetime.

20. LifetimeThe meter is designed for 20-year lifetime at normal operating conditions.

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21. Technical data

Accuracy classActive energy

Reactive energy

Apparent energy

A or B or C (EN 50470 - 3)

Class 2 or 1 (IEC 62053-21)Class 0.5S (IEC 62053-22)

Classes 2, 3 (IEC 62053-23), calibrated up to 1%

Class 2 or 3, calibrated up to 1%Voltages (V)Voltage range 3 x 57.7/100V ... 3 x 240/415V

3x100V … 3x415V (3P3W - external Aaron connection)3x100V … 3x230V (3P3W connection)0.8 - 1.15 Un

Rated impulse voltageGalvanic insulated circuitsVoltage circuits towardsgroundCurrent circuits towardsvoltage circuits (at CTmeters)

6kV

12kV

10kV

FrequencyReference frequency

50 Hz ±2 % or 60Hz ±2%

Currents (A)Direct connection

Indirect connection

Start up current

Short-circuit

0.25 – 5(120)A, (Class A or B)

0.01 – 1(6)A, (Class A or B or C)0.01 – 1(10)A, (Class A or B or C)0.05 – 5(6)A, (Class A or B or C)0.01 – 5(10)A, (Class A or B or C)0.05 – 5(20)A, (Class A or B or C)

0.002In for class A or B (EN 50470 - 3)0.002In for class 2 or 1 (EN 62053 - 21)

0.001In for class C (EN 50470 - 3)0.001In for class 0.5S (EN 62053 - 21)

30 Imax for direct connected20 Imax for indirect connected

OutputsType

Contact

Permitted load

Pulse length

Transmission distance

PHOTO-MOS voltage-free relay

Make or break contact

25 VA (100 mA, 275 V AC)

From 20 ms to 240 ms (adjustable in steps by 20 ms)

Up to 1 km

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InputsVoltage level

Current consumption

100 – 240 V ACON: U 80 VOFF: U 20 V

< 2 mA @ 50V< 10 mA @ 240V

Self consumption ofcurrent circuit

Self consumption ofvoltage circuits

< 0,1 VA / phase

0.5 W / 1.1 VA (self consumption of voltage circuits, when meter issupplied from the measuring voltages)

0.2 W / 0.4 VA (self consumption of voltage circuits, when meter issupplied from the external voltage)

1.1 W / 3.7 VA (self consumption of the external power supply, whenmeter is supplied from the external voltage)

max. 2.5 W / 3 VA (GSM module)CommunicationIR

CS

RS232

RS485

Protocols

Max. 19200 Baud IEC62056-21

Max. 9600 Baud, passive, CL0 in compliance with DIN 66348, Part 1.

Max. 19200 Baud

Max. 19200 Baud

62056-21 mode C with or without a password.LED output Impulse frequency 40 Hz

Impulse length approx. 8 msReal time clockAccuracy

Back-up power supply

Crystal: 6 ppm = 3 min./year (at Top= +25C)

Super-Cap: 0.1F and Li-batteryExternal power supply 50 - 240 V AC/DC

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EMCImmunity to electrostaticdischarges

Immunity toelectromagnetic RF fields

Fast transient burst test

Insulation strength

Rated impulse voltage

Immunity to conducteddisturbances, induced byradio-frequency fields

Surge immunity test

Damped oscillatory wavesimmunity test

Radio interferencesuppression

Glow wire test

Spring hammer test

15 kV (EN 61000-4-2:1995)

Test with current : unmodulated test field strength: 10 V/mTest without current : unmodulated test field strength: 30 V/m(IEC 61000-4-3 Ed.3.0)

4 kV IEC 61000-4-4 Ed.2.0

4 kVrms, 50 Hz, 1 min

Voltage measurement circuit: 12kVCurrent measurement circuit: 10kV (for CT operated meter)All circuits with a reference voltage over 40V: 6kV

voltage level: 10 V IEC 61000-4-6

4kV IEC 61000-4-5

- common mode- 2,5 kV;- differential mode: 1,0 kV; IEC 61000-4-12

CISPR22

IEC 695-2-1

IEC 60068-2-75

Ingress protectionIEC 60529

IP 53

Protection classIEC 62052-11Temperature rangesOperation

Storing

-40C ... +70C

-40C ... +80CClimatic conditionsHumidity > 95%Altitude 2000mType of meter Indoor meterMechanical conditions Meter passed all mechanical tests like shock and vibration testsTerminals (diameter) CT connection: 5 mm (2 screws per terminal)

Direct connection: 9.5 mm (one screw per terminal)Dimensions 327 x 177 x 90 mmMass Approx. 1.4 kg

Table 8: Technical data

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22. Type designation

22.1. Meter type designation

M T 83x – D2 (T1) AnmRnmSnm – EnVn2Lnm – M3 K0xZ4

MT83x three-phase multi-function four-quadrant electronic meter with threemeasuring systems

0 closed (basis) version of the meter1 modular version of the meter

D2 a meter for direct connection and max. current 120 AT1 transformer operated meter and max. current 20 AA Active energy

n = 3 class 0.5S, C (IEC 62053-22, EN 50470-3)n = 4 class 1, B (IEC 62053-21, EN 50470-3)n = 5 class 2, A (IEC 62053-21, EN 50470-3)

m = 1 one energy flow directionm = 2 two energy flow directions

R Reactive energyn = 4 class 2 (IEC 62053 – 23), calibrated to 1%n = 5 class 2 (IEC 62053 – 23)n = 6 class 3 (IEC 62053 – 23)

m = 1 reactive energy flow in one direction (Q+ = Q1 + Q2)m = 2 reactive energy flow in two directions (Q+ = Q1 + Q2 and

Q-=Q3 + Q4)m = 3 inductive reactive energy - reception, capacitive reactive energy

transmission (Q1 and Q4)m = 4 inductive reactive energy in two directions (Q1 in Q3)m = 5 measurement of reactive energy in four quadrants (Q1, Q2, Q3 and Q4)m = 6 measurement of reactive energy in four quadrants, reception and

transmission (Q1, Q2, Q3, Q4 Q+ and Q-)S Apparent energy

n = 4 adjusted to 1%n = 5 adjusted to 2%n = 6 adjusted to 3%

m = 3 apparent energy P2 + Q2

E External power supplyn = 1 power supply of the whole metern = 2 power supply via the optical probe (reading if measuring voltages are

absent)V Control inputs

n = 1..2 a number of inputs2 control voltage is phase voltage

L OptoMOS relay outputsn=1..4 a number of outputs

m = 1 make contactm = 2 optoMOS relay

M Additional device3 real time clock + Li battery

K Communication interface0 first interface: IR – optical interface

1 second interface: CS-interface (20 mA current loop) (MT830 only)2 second interface: RS-232 (MT830 only)3 second interface: RS-485 (MT830 only)

Z Load profile recorder4 memory capacity for load profile 512k FLASH

ROM

36


22.2. Input-output module type designation (for MT831 meter only)

MIO - Vn2 Ln1 B11

MIO Input output moduleV Control inputs

n = 1..4 a number of inputs2 control voltage is phase voltage

L OptoMOS relay outputsn = 1..8 a number of outputs

1 make contactB Relay outputs

n = 1 5A bistable relay

22.2.1. Input/output module options:

MIO – V12L51MIO – V42L81MIO – V12L41B11

Input/output module MIO – V12L51

Figure 25: MIO – input/output module

Module marking:

Connection diagram

Input/output moduleterminals

37


Example of factory preprogrammed module (function of the terminals are defined in the module):

Common G 15External synchronization (forclock/demand period) Active MPE 16

Common G 35Measuring period make contact MPA 37

Common G 40Pulse output for active energy +A make contact +AA 41Pulse output for active energy -A make contact +AA 42Pulse output for reactive energy +R make contact +RA 43Pulse output for reactive energy -R make contact -AA 44

Figure 26: MIO module terminals

22.3. Communication module type designation (for MT831 meters only)

MK – f3n - m

MK Communication modulef active CS- interface (20 mA current loop) – for multidrop communication1 passive CS- interface (20 mA current loop)2 RS-232 interface3 RS-485 interface–for multidrop communication (module with modem)n = 7..9,a,e the first communication interface (type of modem)

n = 7 PSTN modemn = 8 GSM modemn = 9 ISDN modemn = a GSM/GPRS modemn = e Ethernet

m the second communication interfacem = 1 passive CS - interface (20 mA current loop)m = 2 RS-232 interfacem = 3 RS-485 interface

22.3.1. Communication module options:

MK – 2 – 3 (RS-232 & RS-485 interface)MK – 1 – 3 (CS interface & RS-485 interface)MK – 3 – 3 (RS-485 interface & RS-485 interface)MK – f37 – 3 (PSTN modem+CS+RS-485 interface & RS-485 interface) module enables multidrop communication

38


MK – f38 – 3 (GSM modem+CS+RS-485 interface & RS-485 interface) module enables multidropcommunication

MK – f39 – 3 (ISDN modem+CS+RS-485 interface & RS-485 interface) module enables multidrop communicationMK – 38a – 3 (GSM/GPRS modem +RS-485 interface & RS-485 interface) module enables multidrop

communicationMK – 3e – 3 (Ethernet+RS-485 & RS-485 interface) module enables multidrop communication

MK-MB-3-e-3 (MODBUS; Ethernet interface+ RS-485 & RS-485 interface) module enables multidropCommunication

GSM/GPRS communication module MK-38a-3:

Figure 27: GSM/GPRS communication module MK-38a-3

GSM communication module MK – f38 – 3:

Figure 28: GSM communication module MK–f38–3

Connector for FME antenna

Two RS485 interfaces

39


Figure 29: Module marking and connection diagram on communication module

Figure 30: SIM card holder at the GSM communication module

Module marking: MK-38a-3

Connection diagram

40


Installation of the SIM card (SIM card must be enabled for data transfer):

1. Remove the GSM or GSM/GPRS module from the meter.

Figure 31a: Installation of the SIM card

2. SIM card must be without PIN code.3. Insert the SIM card into the SIM cardholder.

Figure 31b: Installation of the SIM card

Figure 31c: Installation of the SIM card

4. Insert the GSM module back into the meter.5. Connect the antenna with the modem.

Figure 31d: Installation of the SIM card – connecting the antenna

Move lock to the left,to enable openingthe SIM cardholder!

41


6. With the DIAG menu on the meter (accessible with the black button), the following can be checked: C.C.3 a signal level (should be higher than 17), C.C.4 GSM provider (1 – home provider, 5 – roaming), C.C.5 error code (should be 0).

23. Configuring a PC modemThe general method of installing a modem is described below. You should follow the instructions given by your modem'smanufacturer if different from any information given here.

The most effective way to use a modem with Meter View is to properly install it in Windows. To do this, launch WindowsControl Panel (click the Windows Start button, click Settings if you see this option, then click Control Panel) and start thePhone and Modem Settings applet.Click the Modems tab and you should see the following window.

Figure 32: The Windows - Control Panel - Phone and Modem Options window.

The contents of the list of modems will depend on your current system configuration.To add a modem, click Add... to see the Windows Add Hardware Wizard and follow the on-screen instructions.If your modem is connected to your computer, it is a good idea to do a diagnostic check when you return to theWindows Phone and Modem Options window. To do this, select the newly added device and click Properties. Click theDiagnostics tab in the window and a window that closely resembles the following is displayed. The specific details of thedisplayed window depend on the modem make and model.

The image cannot be displayed. Your computer may not have enough memory to open the image, or the image may have been corrupted. Restart your computer, and then open the file again. If the red x still appears, you may have to delete the image and then insert it again.

42


Figure 33: Windows Modem Properties window

Click the Query Modem button to see that the Command and Response list is populated and that no error messages aredisplayed.If your modem requires additional commands to select the correct mode of operation, click the Advanced tab to see thefollowing window.

Figure 34: Settings of modem

Consult your modem documentation on the commands available to you.

Communication with the MT83x meters is performed in compliance with the IEC 1107 standard with Mode C protocol.

Type of communication: Serial asynchronous half-duplex ISO 1177 1 start bit 7 data bits 1 bit parity - even



43


1 stop bitData transfer rate: 300, 600, 1200, 2400, 4800, 9600 Baud.

Appropriate modem settings:

Figure 35a: Communication settings

Figure 35b: Communication settings

44


Figure 35c: Communication settings

Check also FIFO buffer settings (especially for XP windows):

Figure 36: Port settings

45


Figure 37: Communication settings

Advanced

Figure 38a: COM settings

or

46


Figure 38b: COM settings

Figure 38c: COM settings

47


24. Appendix A: OBIS codes and data namesOBIS code Data nameThree phases energy registers, t = TOU registers (1,..n)1-0:1.8.0 A+, Active energy import, total register1-0:1.8.t A+, Active energy import, TOU register1-0:1.9.0 A+, Active energy import in the billing period, total register1-0:1.9.t A+, Active energy import in the billing period, TOU register1-0:2.8.0 A-, Active energy export, total register1-0:2.8.t A-, Active energy export, TOU register1-0:2.9.0 A-, Active energy export in the billing period, total register1-0:2.9.t A-, Active energy export in the billing period, TOU register1-0:3.8.0 Q+=Q1+ Q2, Reactive energy import, total register1-0:3.8.t Q+=Q1+ Q2, Reactive energy import, TOU register1-0:3.9.0 Q+=Q1+ Q2, Reactive energy import in the billing period, total register1-0:3.9.t Q+=Q1+ Q2, Reactive energy import in the billing period, TOU register1-0:4.8.0 Q-=Q3+ Q4, Reactive energy export, total register1-0:4.8.t Q-=Q3+ Q4, Reactive energy export, TOU register1-0:4.9.0 Q-=Q3+ Q4, Reactive energy export in the billing period, total register1-0:4.9.t Q-=Q3+ Q4, Reactive energy export in the billing period, TOU register1-0:5.8.0 Q1, Reactive energy, inductive import, total register1-0:5.8.t Q1, Reactive energy, inductive import, TOU register1-0:5.9.0 Q1, Reactive energy, inductive import in the billing period, total register1-0:5.9.t Q1, Reactive energy, inductive import in the billing period, TOU register1-0:6.8.0 Q2, Reactive energy, capacitive import, total register1-0:6.8.t Q2, Reactive energy, capacitive import, TOU register1-0:6.9.0 Q2, Reactive energy, capacitive import in the billing period, total register1-0:6.9.t Q2, Reactive energy, capacitive import in the billing period, TOU register1-0:7.8.0 Q3, Reactive energy, inductive export, total register1-0:7.8.t Q3, Reactive energy, inductive export, TOU register1-0:7.9.0 Q3, Reactive energy, inductive export in the billing period, total register1-0:7.9.t Q3, Reactive energy, inductive export in the billing period, TOU register1-0:8.8.0 Q4, Reactive energy, capacitive export, total register1-0:8.8.t Q4, Reactive energy, capacitive export, TOU register1-0:8.9.0 Q4, Reactive energy, capacitive export in the billing period, total register1-0:8.9.t Q4, Reactive energy, capacitive export in the billing period, TOU register1-0:9.8.0 S+, Apparent energy import, total register1-0:9.8.t S+, Apparent energy import, TOU register1-0:9.9.0 S+, Apparent energy import in the billing period, total register1-0:9.9.t S+, Apparent energy import in the billing period, TOU register1-0:10.8.0 S-, Apparent energy export, total register1-0:10.8.t S-, Apparent energy export, TOU register1-0:10.9.0 S-, Apparent energy export in the billing period, total register1-0:10.9.t S-, Apparent energy export in the billing period, TOU registerThree phases cumulative demand registers, t = TOU registers (1,..n)1-0:1.2.0 P+ cumulative demand total register1-0:1.2.t P+ cumulative demand TOU register1-0:2.2.0 P- cumulative demand total register1-0:2.2.t P- cumulative demand TOU register

48


OBIS code Data name1-0:3.2.0 Q+ cumulative demand total register1-0:3.2.t Q+ cumulative demand TOU register1-0:4.2.0 Q- cumulative demand total register1-0:4.2.t Q- cumulative demand TOU register1-0:5.2.0 Q1 cumulative demand total register1-0:5.2.t Q1 cumulative demand TOU register1-0:6.2.0 Q2 cumulative demand total register1-0:6.2.t Q2 cumulative demand TOU register1-0:7.2.0 Q3 cumulative demand total register1-0:7.2.t Q3 cumulative demand TOU register1-0:8.2.0 Q4 cumulative demand total register1-0:8.2.t Q4 cumulative demand TOU register1-0:9.2.0 S+ cumulative demand total register1-0:9.2.t S+ cumulative demand TOU register1-0:10.2.0 S- cumulative demand total register1-0:10.2.t S- cumulative demand TOU registerThree phases momentary demand registers1-0:1.4.0 P+ momentary demand register1-0:2.4.0 P- momentary demand register1-0:3.4.0 Q+ momentary demand register1-0:4.4.0 Q- momentary demand register1-0:5.4.0 Q1 momentary demand register1-0:6.4.0 Q2 momentary demand register1-0:7.4.0 Q3 momentary demand register1-0:8.4.0 Q4 momentary demand register1-0:9.4.0 S+ momentary demand register1-0:10.4.0 S- momentary demand registerThree phases last ended measurement period demand register1-0:1.5.0 P+ last ended measurement period demand register1-0:2.5.0 P- last ended measurement period demand register1-0:3.5.0 Q+ last ended measurement period demand register1-0:4.5.0 Q- last ended measurement period demand register1-0:5.5.0 Q1 last ended measurement period demand register1-0:6.5.0 Q2 last ended measurement period demand register1-0:7.5.0 Q3 last ended measurement period demand register1-0:8.5.0 Q4 last ended measurement period demand register1-0:9.5.0 S+ last ended measurement period demand register1-0:10.5.0 S- last ended measurement period demand registerThree phases maximum demand registers, t = TOU registers (1,..n)1-0:1.6.0 P+ maximum demand total register1-0:1.6.t P+ maximum demand TOU register1-0:2.6.0 P- maximum demand total register1-0:2.6.t P- maximum demand TOU register1-0:3.6.0 Q+ maximum demand total register1-0:3.6.t Q+ maximum demand TOU register1-0:4.6.0 Q- maximum demand total register1-0:4.6.t Q- maximum demand TOU register

49


OBIS code Data name1-0:5.6.0 Q1 maximum demand total register1-0:5.6.t Q1 maximum demand TOU register1-0:6.6.0 Q2 maximum demand total register1-0:6.6.t Q2 maximum demand TOU register1-0:7.6.0 Q3 maximum demand total register1-0:7.6.t Q3 maximum demand TOU register1-0:8.6.0 Q4 maximum demand total register1-0:8.6.t Q4 maximum demand TOU register1-0:9.6.0 S+ maximum demand total register1-0:9.6.t S+ maximum demand TOU register1-0:10.6.0 S- maximum demand total register1-0:10.6.t S- maximum demand TOU registerThree phases quality instantaneous registers1-0:11.7.0 Average current RMS1-0:12.7.0 Average voltage RMS1-0:13.7.0 Average power factor1-0:14.7.0 Average frequency1-0:11.7.h Average harmonics component in current, h – harmonics component (1, ..,8)1-0:12.7.h Average harmonics component in voltage, h – harmonics component (1, ..,8)1-0: 15.7.0 ΣLi Active power (abs(QI+QIV)+(abs(QII+QIII))Phase R energy registers, t = TOU registers (1,..n)1-0:21.8.0 A+, Active energy import in phase R, total register1-0:21.8.t A+, Active energy import in phase R, TOU register1-0:21.9.0 A+, Active energy import in the billing period, phase R1-0:21.9.t A+, Active energy import in the billing period TOU register, phase R1-0:22.8.0 A-, Active energy export in phase R, total register1-0:22.8.t A-, Active energy export in phase R, TOU register1-0:22.9.0 A-, Active energy export in the billing period, phase R1-0:22.9.t A-, Active energy export in the billing period TOU register, phase R1-0:23.8.0 Q+=Q1+ Q2, Reactive energy import in phase R, total register1-0:23.8.t Q+=Q1+ Q2, Reactive energy import in phase R, TOU register1-0:23.9.0 Q+=Q1+ Q2, Reactive energy import in the billing period, phase R1-0:23.9.t Q+=Q1+ Q2, Reactive energy import in the billing period TOU register, phase R1-0:24.8.0 Q-=Q3+ Q4, Reactive energy export in phase R, total register1-0:24.8.t Q-=Q3+ Q4, Reactive energy export in phase R, TOU register1-0:24.9.0 Q-=Q3+ Q4, Reactive energy export in the billing period, phase R1-0:24.9.t Q-=Q3+ Q4, Reactive energy export in the billing period TOU register, phase R1-0:25.8.0 Q1, Reactive energy, inductive import in phase R, total register1-0:25.8.t Q1, Reactive energy, inductive import in phase R, TOU register1-0:25.9.0 Q1, Reactive energy, inductive import in the billing period, phase R1-0:25.9.t Q1, Reactive energy, inductive import in the billing period TOU register, phase R1-0:26.8.0 Q2, Reactive energy, capacitive import in phase R, total register1-0:26.8.t Q2, Reactive energy, capacitive import in phase R, TOU register1-0:26.9.0 Q2, Reactive energy, capacitive import in the billing period, phase R1-0:26.9.t Q2, Reactive energy, capacitive import in the billing period TOU register, phase R1-0:27.8.0 Q3, Reactive energy, inductive export in phase R, total register1-0:27.8.t Q3, Reactive energy, inductive export in phase R, TOU register

50


OBIS code Data name1-0:27.9.0 Q3, Reactive energy, inductive export in the billing period, phase R1-0:27.9.t Q3, Reactive energy, inductive export in the billing period TOU register, phase R1-0:28.8.0 Q4, Reactive energy, capacitive export in phase R, total register1-0:28.8.t Q4, Reactive energy, capacitive export in phase R, TOU register1-0:28.9.0 Q4, Reactive energy, capacitive export in the billing period, phase R1-0:28.9.t Q4, Reactive energy, capacitive export in the billing period TOU register, phase R1-0:29.8.0 S+, Apparent energy import in phase R, total register1-0:29.8.t S+, Apparent energy import in phase R, TOU register1-0:29.9.0 S+, Apparent energy import in the billing period, phase R1-0:29.9.t S+, Apparent energy import in the billing period TOU register, phase R1-0:30.8.0 S- Apparent energy export in phase R, total register1-0:30.8.t S- Apparent energy export in phase R, TOU register1-0:30.9.0 S-, Apparent energy export in the billing period, phase R1-0:30.9.t S-, Apparent energy export in the billing period TOU register, phase RPhase R cumulative demand register, t = TOU registers (1,..n)1-0:21.2.0 P+ cumulative demand in phase R total register1-0:21.2.t P+ cumulative demand in phase R TOU register1-0:22.2.0 P- cumulative demand in phase R total register1-0:22.2.t P- cumulative demand in phase R TOU register1-0:23.2.0 Q+ cumulative demand in phase R total register1-0:23.2.t Q+ cumulative demand in phase R TOU register1-0:24.2.0 Q- cumulative demand in phase R total register1-0:24.2.t Q- cumulative demand in phase R TOU register1-0:25.2.0 Q1 cumulative demand in phase R total register1-0:25.2.t Q1 cumulative demand in phase R TOU register1-0:26.2.0 Q2 cumulative demand in phase R total register1-0:26.2.t Q2 cumulative demand in phase R TOU register1-0:27.2.0 Q3 cumulative demand in phase R total register1-0:2.2.t Q3 cumulative demand in phase R TOU register1-0:28.2.0 Q4 cumulative demand in phase R total register1-0:28.2.t Q4 cumulative demand in phase R TOU register1-0:29.2.0 S+ cumulative demand in phase R total register1-0:29.2.t S+ cumulative demand in phase R TOU register1-0:30.2.0 S- cumulative demand in phase R total register1-0:30.2.t S- cumulative demand in phase R TOU registerPhase R momentary demand register1-0:21.4.0 P+ momentary demand in phase R register1-0:22.4.0 P- momentary demand in phase R register1-0:23.4.0 Q+ momentary demand in phase R register1-0:24.4.0 Q- momentary demand in phase R register1-0:25.4.0 Q1 momentary demand in phase R register1-0:26.4.0 Q2 momentary demand in phase R register1-0:27.4.0 Q3 momentary demand in phase R register1-0:28.4.0 Q4 momentary demand in phase R register1-0:29.4.0 S+ momentary demand in phase R register1-0:30.4.0 S- momentary demand in phase R register

51


OBIS code Data namePhase R last ended measurement period demand register1-0:21.5.0 P+ last ended measurement period in phase R demand register1-0:22.5.0 P- last ended measurement period in phase R demand register1-0:23.5.0 Q+ last ended measurement period in phase R demand register1-0:24.5.0 Q- last ended measurement period in phase R demand register1-0:25.5.0 Q1 last ended measurement period in phase R demand register1-0:26.5.0 Q2 last ended measurement period in phase R demand register1-0:27.5.0 Q3 last ended measurement period in phase R demand register1-0:28.5.0 Q4 last ended measurement period in phase R demand register1-0:29.5.0 S+ last ended measurement period in phase R demand register1-0:30.5.0 S- last ended measurement period in phase R demand registerPhase R maximum demand registers, t = TOU registers (1,..n)1-0:21.6.0 P+ maximum demand in phase R register1-0:21.6.t P+ maximum demand in phase R TOU register1-0:22.6.0 P- maximum demand in phase R register1-0:22.6.t P- maximum demand in phase R TOU register1-0:23.6.0 Q+ maximum demand in phase R register1-0:23.6.t Q+ maximum demand in phase R TOU register1-0:24.6.0 Q- maximum demand in phase R register1-0:24.6.t Q- maximum demand in phase R TOU register1-0:25.6.0 Q1 maximum demand in phase R register1-0:25.6.t Q1 maximum demand in phase R TOU register1-0:26.6.0 Q2 maximum demand in phase R register1-0:26.6.t Q2 maximum demand in phase R TOU register1-0:27.6.0 Q3 maximum demand in phase R register1-0:27.6.t Q3 maximum demand in phase R TOU register1-0:28.6.0 Q4 maximum demand in phase R register1-0:28.6.t Q4 maximum demand in phase R TOU register1-0:29.6.0 S+ maximum demand in phase R register1-0:29.6.t S+ maximum demand in phase R TOU register1-0:30.6.0 S- maximum demand in phase R register1-0:30.6.t S- maximum demand in phase R TOU registerPhase R quality instantaneous registers1-0:31.7.0 Average current RMS in phase R1-0:32.7.0 Average voltage RMS in phase R1-0:33.7.0 Average power factor in phase R1-0:34.7.0 Average frequency in phase R1-0:31.7.h Average harmonics component in current, h – harmonics component (1, ..,8) in phase

R1-0:32.7.h Average harmonics component in voltage, h – harmonics component (1, ..,8) in phaseR1-0:81.7.40 Phase angle in phase R

Phase S energy registers, t = TOU registers (1,..n)1-0:41.8.0 A+, Active energy import in phase S, total register1-0:41.8.t A+, Active energy import in phase S, total register1-0:41.9.0 A+, Active energy import in the billing period, phase S1-0:41.9.t A+, Active energy import in the billing period, phase S1-0:42.8.0 A-, Active energy export in phase S, total register1-0:42.8.t A-, Active energy export in phase S, total register

52


OBIS code Data name1-0:42.9.0 A-, Active energy export in the billing period, phase S1-0:42.9.t A-, Active energy export in the billing period, phase S1-0:43.8.0 Q+=Q1+ Q2, Reactive energy import in phase S, total register1-0:43.8.t Q+=Q1+ Q2, Reactive energy import in phase S, total register1-0:43.9.0 Q+=Q1+ Q2, Reactive energy import in the billing period, phase S1-0:43.9.t Q+=Q1+ Q2, Reactive energy import in the billing period, phase S1-0:44.8.0 Q-=Q3+ Q4, Reactive energy export in phase S, total register1-0:44.8.t Q-=Q3+ Q4, Reactive energy export in phase S, total register1-0:44.9.0 Q-=Q3+ Q4, Reactive energy export in the billing period, phase S1-0:44.9.t Q-=Q3+ Q4, Reactive energy export in the billing period, phase S1-0:45.8.0 Q1, Reactive energy, inductive import in phase S, total register1-0:45.8.t Q1, Reactive energy, inductive import in phase S, total register1-0:45.9.0 Q1, Reactive energy, inductive import in the billing period, phase S1-0:45.9.t Q1, Reactive energy, inductive import in the billing period, phase S1-0:46.8.0 Q2, Reactive energy, capacitive import in phase S, total register1-0:46.8.t Q2, Reactive energy, capacitive import in phase S, total register1-0:46.9.0 Q2, Reactive energy, capacitive import in the billing period, phase S1-0:46.9.t Q2, Reactive energy, capacitive import in the billing period, phase S1-0:47.8.0 Q3, Reactive energy, inductive export in phase S, total register1-0:47.8.t Q3, Reactive energy, inductive export in phase S, total register1-0:47.9.0 Q3, Reactive energy, inductive export in the billing period, phase S1-0:47.9.t Q3, Reactive energy, inductive export in the billing period, phase S1-0:48.8.0 Q4, Reactive energy, capacitive export in phase S, total register1-0:48.8.t Q4, Reactive energy, capacitive export in phase S, total register1-0:48.9.0 Q4, Reactive energy, capacitive export in the billing period, phase S1-0:48.9.t Q4, Reactive energy, capacitive export in the billing period, phase S1-0:49.8.0 S+, Apparent energy import in phase S, total register1-0:49.8.t S+, Apparent energy import in phase S, total register1-0:49.9.0 S+, Apparent energy import in the billing period, phase S1-0:49.9.t S+, Apparent energy import in the billing period, phase S1-0:50.8.0 S-, Apparent energy export in phase S, total register1-0:50.8.t S-, Apparent energy export in phase S, total register1-0:50.9.0 S-, Apparent energy export in the billing period, phase S1-0:50.9.t S-, Apparent energy export in the billing period, phase SPhase S momentary demand register1-0:41.4.0 P+ momentary demand in phase S register1-0:42.4.0 P- momentary demand in phase S register1-0:43.4.0 Q+ momentary demand in phase S register1-0:44.4.0 Q- momentary demand in phase S register1-0:45.4.0 Q1 momentary demand in phase S register1-0:46.4.0 Q2 momentary demand in phase S register1-0:47.4.0 Q3 momentary demand in phase S register1-0:48.4.0 Q4 momentary demand in phase S register1-0:49.4.0 S+ momentary demand in phase S register1-0:50.4.0 S- momentary demand in phase S registerPhase S last ended measurement period demand register1-0:41.5.0 P+ last ended measurement period in phase S demand register

53


OBIS code Data name1-0:42.5.0 P- last ended measurement period in phase S demand register1-0:43.5.0 Q+ last ended measurement period in phase S demand register1-0:44.5.0 Q- last ended measurement period in phase S demand register1-0:45.5.0 Q1 last ended measurement period in phase S demand register1-0:46.5.0 Q2 last ended measurement period in phase S demand register1-0:47.5.0 Q3 last ended measurement period in phase S demand register1-0:48.5.0 Q4 last ended measurement period in phase S demand register1-0:49.5.0 S+ last ended measurement period in phase S demand register1-0:50.5.0 S- last ended measurement period in phase S demand registerPhase S maximum demand registers, t = TOU registers (1,..n)1-0:41.6.0 P+ maximum demand in phase S register1-0:41.6.t P+ maximum demand in phase S TOU register1-0:42.6.0 P- maximum demand in phase S register1-0:42.6.t P- maximum demand in phase S TOU register1-0:43.6.0 Q+ maximum demand in phase S register1-0:43.6.t Q+ maximum demand in phase S TOU register1-0:44.6.0 Q- maximum demand in phase S register1-0:44.6.t Q- maximum demand in phase S TOU register1-0:45.6.0 Q1 maximum demand in phase S register1-0:45.6.t Q1 maximum demand in phase S TOU register1-0:46.6.0 Q2 maximum demand in phase S register1-0:46.6.t Q2 maximum demand in phase S TOU register1-0:47.6.0 Q3 maximum demand in phase S register1-0:47.6.t Q3 maximum demand in phase S TOU register1-0:48.6.0 Q4 maximum demand in phase S register1-0:48.6.t Q4 maximum demand in phase S TOU register1-0:49.6.0 S+ maximum demand in phase S register1-0:49.6.t S+ maximum demand in phase S TOU register1-0:50.6.0 S- maximum demand in phase S register1-0:50.6.t S- maximum demand in phase S TOU registerPhase S quality instantaneous registers1-0:51.7.0 Average current RMS in phase S1-0:52.7.0 Average voltage RMS in phase S1-0:53.7.0 Average power factor in phase S1-0:54.7.0 Average frequency in phase S1-0:51.7.h Average harmonics component in current, h – harmonics component (1, ..,8) in phase

S1-0:52.7.h Average harmonics component in voltage, h – harmonics component (1, ..,8) in phaseS1-0:81.7.51 Phase angle in phase S

Phase T energy registers, t = TOU registers (1,..n)1-0:61.8.0 A+, Active energy import in phase T, total register1-0:61.8.t A+, Active energy import in phase T, total register1-0:61.9.0 A+, Active energy import in the billing period, phase T1-0:61.9.t A+, Active energy import in the billing period, phase T1-0:62.8.0 A-, Active energy export in phase T, total register1-0:62.8.t A-, Active energy export in phase T, total register1-0:62.9.0 A-, Active energy export in the billing period, phase T1-0:62.9.t A-, Active energy export in the billing period, phase T

54


OBIS code Data name1-0:63.8.0 Q+=Q1+ Q2, Reactive energy import in phase T, total register1-0:63.8.t Q+=Q1+ Q2, Reactive energy import in phase T, total register1-0:63.9.0 Q+=Q1+ Q2, Reactive energy import in the billing period, phase T1-0:63.9.t Q+=Q1+ Q2, Reactive energy import in the billing period, phase T1-0:64.8.0 Q-=Q3+ Q4, Reactive energy export in phase T, total register1-0:64.8.t Q-=Q3+ Q4, Reactive energy export in phase T, total register1-0:64.9.0 Q-=Q3+ Q4, Reactive energy export in the billing period, phase T1-0:64.9.t Q-=Q3+ Q4, Reactive energy export in the billing period, phase T1-0:65.8.0 Q1, Reactive energy, inductive import in phase T, total register1-0:65.8.t Q1, Reactive energy, inductive import in phase T, total register1-0:65.9.0 Q1, Reactive energy, inductive import in the billing period, phase T1-0:65.9.t Q1, Reactive energy, inductive import in the billing period, phase T1-0:66.8.0 Q2, Reactive energy, capacitive import in phase T, total register1-0:66.8.t Q2, Reactive energy, capacitive import in phase T, total register1-0:66.9.0 Q2, Reactive energy, capacitive import in the billing period, phase T1-0:66.9.t Q2, Reactive energy, capacitive import in the billing period, phase T1-0:67.8.0 Q3, Reactive energy, inductive export in phase T, total register1-0:67.8.t Q3, Reactive energy, inductive export in phase T, total register1-0:67.9.0 Q3, Reactive energy, inductive export in the billing period, phase T1-0:67.9.t Q3, Reactive energy, inductive export in the billing period, phase T1-0:68.8.0 Q4, Reactive energy, capacitive export in phase T, total register1-0:68.8.t Q4, Reactive energy, capacitive export in phase T, total register1-0:68.9.0 Q4, Reactive energy, capacitive export in the billing period, phase T1-0:68.9.t Q4, Reactive energy, capacitive export in the billing period, phase T1-0:69.8.0 S+, Apparent energy import in phase T, total register1-0:69.8.t S+, Apparent energy import in phase T, total register1-0:69.9.0 S+, Apparent energy import in the billing period, phase T1-0:69.9.t S+, Apparent energy import in the billing period, phase T1-0:70.8.0 S-, Apparent energy export in phase T, total register1-0:70.8.t S-, Apparent energy export in phase T, total register1-0:70.9.0 S-, Apparent energy export in the billing period, phase T1-0:70.9.t S-, Apparent energy export in the billing period, phase TPhase T momentary demand register1-0:61.4.0 P+ momentary demand in phase T register1-0:62.4.0 P- momentary demand in phase T register1-0:63.4.0 Q+ momentary demand in phase T register1-0:64.4.0 Q- momentary demand in phase T register1-0:65.4.0 Q1 momentary demand in phase T register1-0:66.4.0 Q2 momentary demand in phase T register1-0:67.4.0 Q3 momentary demand in phase T register1-0:68.4.0 Q4 momentary demand in phase T register1-0:69.4.0 S+ momentary demand in phase T register1-0:70.4.0 S- momentary demand in phase T registerPhase T last ended measurement period demand register1-0:61.5.0 P+ last ended measurement period in phase T demand register1-0:62.5.0 P- last ended measurement period in phase T demand register1-0:63.5.0 Q+ last ended measurement period in phase T demand register

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OBIS code Data name1-0:64.5.0 Q- last ended measurement period in phase T demand register1-0:65.5.0 Q1 last ended measurement period in phase T demand register1-0:66.5.0 Q2 last ended measurement period in phase T demand register1-0:67.5.0 Q3 last ended measurement period in phase T demand register1-0:68.5.0 Q4 last ended measurement period in phase T demand register1-0:69.5.0 S+ last ended measurement period in phase T demand register1-0:70.5.0 S- last ended measurement period in phase T demand registerPhase T maximum demand registers, t = TOU registers (1,..n)1-0:61.6.0 P+ maximum demand in phase T register1-0:61.6.t P+ maximum demand in phase T TOU register1-0:62.6.0 P+ maximum demand in phase T register1-0:62.6.t P- maximum demand in phase T TOU register1-0:63.6.0 Q+ maximum demand in phase T register1-0:63.6.t Q+ maximum demand in phase T TOU register1-0:64.6.0 Q- maximum demand in phase T register1-0:64.6.t Q- maximum demand in phase T TOU register1-0:65.6.0 Q1 maximum demand in phase T register1-0:65.6.t Q1 maximum demand in phase T TOU register1-0:66.6.0 Q2 maximum demand in phase T register1-0:66.6.t Q2 maximum demand in phase T TOU register1-0:67.6.0 Q3 maximum demand in phase T register1-0:67.6.t Q3 maximum demand in phase T TOU register1-0:68.6.0 Q4 maximum demand in phase T register1-0:68.6.t Q4 maximum demand in phase T TOU register1-0:69.6.0 S+ maximum demand in phase T register1-0:69.6.t S+ maximum demand in phase T TOU register1-0:70.6.0 S- maximum demand in phase T register1-0:70.6.t S- maximum demand in phase T TOU registerPhase T quality instantaneous registers1-0:71.7.0 Average current RMS in phase T1-0:72.7.0 Average voltage RMS in phase T1-0:73.7.0 Average power factor in phase T1-0:74.7.0 Average frequency in phase T1-0:71.7.h Average harmonics component in current, h – harmonics component (1, ..,8) in phase

T1-0:72.7.h Average harmonics component in voltage, h – harmonics component (1, ..,8) in phaseT1-0:81.7.62 Phase angle in phase T

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25. Appendix B: Log book eventsLB code Data nameLB.0080 Power downLB.0040 Power upLB.8102 Voltage down phase L1LB.8103 Voltage down phase L2LB.8104 Voltage down phase L3LB.8105 Under-voltage phase L1LB.8106 Under-voltage phase L2LB.8107 Under-voltage phase L3LB.8108 Voltage normal phase L1LB.8109 Voltage normal phase L2LB.810A Voltage normal phase L3LB.810B Over-voltage phase L1LB.810C Over-voltage phase L2LB.810D Over-voltage phase L3LB.810E Billing resetLB.810F RTC sync startLB.8110 RTC sync endLB.0020 RTC SetLB.0008 DSTLB.2000 Log-Book erasedLB.4000 Load-Profile erasedLB.0001 Device disturbanceLB.8117 Parameters changedLB.8118 Watch dogLB.8119 Fraud startLB.811A Fraud endLB.811B Terminal cover openedLB.811C Terminal cover closedLB.811D Main cover openedLB.811E Main cover closedLB.811F Master resetLB.8120 Parameter changed via remote comm.LB.8121 Scheduled parameter changeLB.814E Full Technical Log BookLB.814F Unable to send SMS alarmLB.8150 Intrusion resetLB.8151 Previous values resetLB.8152 Current without Voltage phase L1 - startLB.8153 Current without Voltage phase L2 – startLB.8154 Current without Voltage phase L3 - startLB.8155 Current without Voltage phase L1 - endLB.8156 Current without Voltage phase L2 – endLB.8157 Current without Voltage phase L3 – endLB.815E Wrong password loginLB.815F Password changedLB.8158 COM module inserted - badLB.8159 COM module inserted - OKLB.815A COM module outLB.815B IO module inserted - badLB.815C IO module inserted - OKLB.815D IO module out

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LB code Data nameLB.8160 Start DST changedLB.8161 End DST changedLB.8162 Low batteryLB.8163 Inverted current start phase L1LB.8164 Inverted current end phase L1LB.8165 Inverted current start phase L2LB.8166 Inverted current end phase L2LB.8167 Inverted current start phase L3LB.8168 Inverted current end phase L3LB.8169 Unbalanced by current startLB.816A Unbalanced by current endLB.816B Unbalanced by voltage startLB.816C Unbalanced by voltage endLB.816D External alarmLB.816E Alarm output setLB.8171 External alarm 2LB.8172 External alarm 3LB.8173 External alarm 4

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26. Appendix C: Connection diagrams

Connection diagram for direct connected meter:

Figure 39: Connection diagram for direct connected meter

Connection diagram for transformer operated meter (3phase-4wire connection, connection via current and (or) voltagetransformer):

Figure 40: Connection diagram for transformer operated meter (3phase 4wire)

Connection diagram for transformer operated meter (3phase-3wire connection, connection via current and voltagetransformer):

Figure 41a: Connection diagram for transformer operated meter (3p3w)

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Figure 41b: Connection diagram for transformer operated meter (3p3w)

Figure 41c: Connection diagram for transformer operated meter (3p3w)

Note: Such connection could be used only for maximal nominal voltage 3x230V and with vector registration!

Owing to periodical improvements of our products the supplied products can differ in some details from the data stated in the prospectus material.Iskraemeco d.d., Energy Measurement and Management4000 Kranj, Savska loka 4, SloveniaTelephone (+386 4) 206 40 00, Fax: (+386 4) 206 43 76http://www.iskraemeco.si, E-mail: [email protected] by Iskraemeco. Data subject to alteration without notice. MT830-MT831_TD_eng_V1.7.docx

MT830-MT831_TD_eng_V1.7

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